### Emissions for Modeling Scenarios for EPA**'s Final BA RT Rule for Navajo Generating Station**  **EPA , March 2014**  Latest revision: sjb 2014-03-07 Note that the numbering for the control scenarios is different from that used in the 2009 ANPRM and the 2013 Proposed Rulemaking **Code Name**  **Description Abbreviation**  (e.g. for graphs) unit 1 unit 2 unit 3 **NOx, lb/hr SO2 lb/hr**  F1 SCR is BART SCR+LNB+SOFA on Units 1 - 3 (**0.055 lb/MMBtu** ), SO2

conversion 0.67% SCRall_055 SCR .055 SCR .055 SCR .055 1,506 1,591 F2 TW G A1-2020 Close one unit, LNB+SOFA on remaining two units cl2+LNB LNB (closed) LNB 4,309 1,064 F3 TW G A1-2031 Close one unit, SCR+LNB+SOFA on 2 units (**0.07**

**lb/MMBtu** ), SO2 conversion 0.67% cl2+SCR SCR .07 (closed) SCR .07 1,257 1,064 F4 TW G A2-2020 Close one unit, increase capacity on remaining two units

by 189 MWtotal, LNB+SOFA on two units cl2+incr+LNB incr, LNB (closed) incr, LNB 4,851 1,198 F5 TW G A2-2031 Close one unit, increase capacity on remaining two units

by 189 MWtotal, SCR (**0.07**) on two units cl2+incr+SCR SCR .07 (closed) SCR .07 1,415 1,198 F6 TW G A3-2020 Reduce capacity of Unit 2 by 561 MWtotal; LNB+SOFA

on 3 units curt2+LNB LNB curt, LNB LNB 4,878 1,197 F7 TW G A3-2031a Reduce capacity on Unit 2 by 561 MW , SCR on units 1

and 3 (0.07), LNB+SOFA on unit 2 curt2+SCR13 SCR .07 curt, LNB SCR .07 1,827 1,197 F8 TW G A3-2031b Reduce capacity equally on 3 units with SCR by 561 MW

total; SCR on Units 1 and 3 (0.07). curt123+SCR13 curt, SCR .07 curt, LNB curt, SCR .07 2,639 1,193 F9 TW G A3-2013c Reduce capacity on Units 1 and 3 by 561 MWtotal; SCR

on Units 1 and 3 (0.07) curt13+SCR13 SCR .07, curt LNB SCR .07, curt 3,047 1,192 cl=close, incr=increase, curt=curtail; unit numbers Corresponding spreadsheet tabs have titles combining Code and Name above. The spreadsheet tab "Baseline stack data" has stack parameters. The spreadsheet tab "CALPUFF" has modeling emissions from all scenarios in a single table. 

### Modeling Scenarios from 2013 Notice of Proposed Rulemaking that are still A**pplicable and Used for Final Rule Code**  **Name Description**  **Abbreviation** unit 1 unit 2 unit 3 **NOx, lb/hr SO2 lb/hr**  N0 Baseline 2001 - 2003 baseline Base none none none 12661 1591 N1 Control Option 1 LNB + SOFA on Units 1 - 3, 0.24 lb/MMBtu LNB LNB LNB LNB 6570 1591 N8 Control Option 8 SNCR+LNB+SOFA on Units 1 - 3, NOx at 0.18 lb/MMBtu SNCRhi SNCR .18 SNCR .18 SNCR .18 4928 1591 **NOx controls on the three units Total emissions** 

**NOx controls on the three units Total emissions** **EPA revisions to values used in Proposed Rule** 

MMBtu/day MMBtu/hr % ton/day lb/hr lb/MMBtu % reduction ton/day Navajo 1 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, LNB, SOFA, **SCR**, hot side ESP, wet FGD 211,074 8,795 0.593 5.85 487.75 0.055 89% 5.80

Navajo 2 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, LNB, SOFA, **SCR**, hot side ESP, wet FGD 226,163 9,423 0.593 6.32 526.92 0.056 88% 6.22

Navajo 3 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, LNB, SOFA, **SCR**, hot side ESP, wet FGD 219,778 9,157 0.593 6.91 576.17 0.063 88% 6.04 

## Maximum Emissions Including Speciated PM

**Navajo Units 1, 2, and 3**

Facility Unit Description Maximum SO2 Emissions (c) Maximum NOx Emissions Maximum Heat Input (a) Maximum Sulfur Content (b) 

## f1: Low**NOx Burners, Separated Overfire A ir, and Selective Cataly**  **tic Reduction (Units 1, 2 & 3) _ EPA modified to use Ultra-low** **activity cataly** **st and NOx limit**

(a) Maximum daily

24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02. 

### ** Below**are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately** (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03.Unit conversion for ammonia slip from ppmvd to lb/hr NH3 0.75 ppmvd at 6% O2 Method 19 (SO2 removal efficiency) formula, Eq. 19-1:

0.00045 lb/MMBtu E = Cd*Fd*20.9/(20.9 - %O2d) unit 1 3.99 lb/hr Cd = Pollutant concentration, dry basis unit 2 4.27 lb/hr Fd = volum es of combustion components per unit of heat content unit 3 4.15 lb/hr %O2d = Concentration of oxygen on a dry basis, percent. Table 19-2 gives F factor for bituminous coal as Fd = 9780 sdcf/10^6 Btu

(6) The 0.63 ESP penetration is applied to H2SO4 before the ammonia reaction, which mainly occurs in the lower temperatures of the air preheater. SCR conversion of SO2 to SO3 99.50% = fraction SO2 remaining after 3 layers, corresponding to 0.5% conversion layers conversion

1 0.17% 2 0.33% 3 0.50% 4 0.67% (5) Ammonia slip calculation only affects split between H2SO4 and ammonium sulfate/bisulfate. Since in this case there is no ammonia slip, and controls are assumed to affect all these the same way, the split is irrelevant, and only total am ount of SO4 matters for modeling. (Since all SO4 forms are assumed to be affected the same way, the SO4 for modeling can also be calculated directly from H2SO4 * 96.06/98.08.) (3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for PRB coal (strongly alkaline coal) (4) 0.67% SO2 to SO3 conversion efficiency : Three layers give 0.5% conversion; may not have 4th till 3rd year, but conservatively assume all in four place at start. 1 - (1 - 0.005)^(3/4) or 0.005*4/3 are both about 0.0067 = 0.67%, see below (k) Ammonia slip is 0.75 ppmvd at 6% O2 for SCR. (l) Ammonia is assumed to react with SO4 to form ammonium sulfate per EPRI 2008 if the molecules of NH3 are at least twice those of H2SO4; otherwise, ammonium bisulfate is formed.

(2) in sulfuric acid calculation, revised penetration factor for hot-side ESP from 1 (used in ANPRM) to 0.63. 

### EPA **revisions to Values used in A NPRM (3-7-11)**  (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. EPRI (2008) Eqn 4-2b indicates that 95% of fuel sulfur is converted to SO2.

(1) set HCl and HF to zero (j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998. (d) Maximum daily

/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. (h) Total condensable PM10 is the sum of H2SO4 and organic condensable PM10 emissions. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or malfunction. (f) For a dry

bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (e) Maximum of 6 stack test results for the 2001 to 2006 period.Penetration factors H2SO4 AbS and AS PM, general p % ctrl p % ctrl p % ctrl hot-side ESP 0.63 37% 0.01 99% 0.01 99% Air Preheater 0.50 50% 0.75 25% Wet FGD (scrubber) 0.47 53% 0.50 50% EPRI H2SO4 doc EPRI NH3 docfine total fine soil EC

lb/hr lb/MMBtu lb/MMBtu (e) lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr
483.71 **0.055** 0.026 228.66 153.20 (f) 86.89 (f) 66.31 (f) 63.9 (g) 2.45 (g) 51.88 (h) 16.70 (i) 16.36

518.29 **0.055** 0.021 197.89 132.59 (f) 75.20 (f) 57.39 (f) 55.3 (g) 2.12 (g) 55.59 (h) 17.89 (i) 17.53

503.66 **0.055** 0.031 283.88 190.20 (f) 107.87 (f) 82.33 (f) 79.3 (g) 3.05 (g) 54.02 (h) 17.39 (i) 17.03 

## Maximum Emissions Including Speciated PM **10**

## Emissions

**Navajo Units 1, 2, and 3**
Filterable PM 10 Condensable PM 10 Maximum Filterable PM Em issions Maximum NOx Emissions (d) SO4 

## f1: Low**NOx Burners, Separated Overfire A ir, and Selective Cataly**  **tic Reduction (Units 1, 2 & 3) _ EPA modified to use Ultra-low** **activity cataly** **st and NOx limit 0.055 lb/MMBtu** 

(a) Maximum daily

24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02. H2SO4



### ** Below**are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately** (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. total coarse Fine totalMethod 19 (SO2 removal efficiency) formula, Eq. 19-1: Atm osphere is 20.9% oxygen Cd = Pollutant concentration, dry basis Am monia M.W . is 17 lb/lb.mol Fd = volum es of combustion components per unit of heat content 385 ft3/lb-mol = volume of 1 ft3 of gas at STP %O2d = Concentration of oxygen on a dry basis, percent. Table 19-2 gives F factor for bituminous coal as Fd = 9780 sdcf/10^6 Btu

(6) The 0.63 ESP penetration is applied to H2SO4 before the ammonia reaction, which mainly occurs in the lower temperatures of the air preheater. (5) Ammonia slip calculation only affects split between H2SO4 and ammonium sulfate/bisulfate. Since in this case there is no ammonia slip, and controls are assumed to affect all these the same way, the split is irrelevant, and only total am ount of SO4 matters for modeling. (Since all SO4 forms are assumed to be (3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for PRB coal (4) 0.67% SO2 to SO3 conversion efficiency : Three layers give 0.5% conversion; may not have 4th till 3rd year, but conservatively assume all in four place at start. 1 - (1 - 0.005)^(3/4) or 0.005*4/3 are both about 0.0067 = 0.67%, see below (l) Ammonia is assumed to react with SO4 to form ammonium sulfate per EPRI 2008 if the molecules of NH3 are at least twice those of H2SO4; otherwise, ammonium bisulfate is formed. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. (d) Maximum daily

/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or malfunction. (f) For a dry

bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002.lb/hr lb/hr lb/hr lb m ole/hr lb m ole/hr mole ratio lb m ole/hr lb m ole/hr lb m ole/hr lb m ole/hr lb/hr lb/hr

35.18 (j) 71.06 3.99 (k) 0.234 0.724 0.323 0.490 0.234 0.000 0.000 **0.00** 17.64

37.69 (j) 76.13 4.27 (k) 0.251 0.776 0.323 0.525 0.251 0.000 0.000 **0.00** 18.90

36.63 (j) 73.99 4.15 (k) 0.244 0.754 0.323 0.510 0.244 0.000 0.000 **0.00** 18.36 organic Am monia slip and reaction with sulfuric acid, for Net ammonia slip and Modeling SO4 Net NH3 after reaction & WF GD [NH3] after reaction [NH3] H2SO4 + AbS + AS post-control [H2SO4] after reaction [NH3] / [H2SO4] ratio [H2SO4] H2SO4 before NH3 interaction, after ESP [AS] or [(NH4)2SO 4] after reaction NH3 Slip [AbS] or [NH4HSO4] after reaction(5) Ammonia slip calculation only affects split between H2SO4 and ammonium sulfate/bisulfate. Since in this case there is no ammonia slip, and controls are assumed to affect all these the same way, the split is irrelevant, and only total am ount of SO4 matters for modeling. (Since all SO4 forms are assumed to be (3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for PRB coal (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or malfunction.

### For copying to Word version of tables Highlight num bers portion of table here, copy; then goto Word, highlight num bers section of its table, paste
**f1: SCR Units 1 - 3** H2SO4 HCl HF HCl + HF HCl+HF+ Pmfine Max Heat Input SO2 NOx lb/hr lb/hr lb/m mbtu lb/m mbtu lb/Mm btu lb/hr new PM fine MMBtu/hr lb/MMBtu lb/MMBtu
**16.35 206.02**  **0.0019** 0 0 0 63.86 Unit 1 8,795 0.06 0.06

**17.52** 189.178 **0.0019** 0 0 0 55.27 Unit 2 9,423 0.06 0.06

**17.03** 245.192 **0.0019** 0 0 0 79.28 Unit 3 9,157 0.06 0.06

Max Heat Input SO2 NOx Total PM10 Total Effective SO4 for modelingMMBtu/hr lb/hr lb/hr Unit 1 8,795 487.75 483.71 Unit 2 9,423 526.92 518.29 Unit 3 9,157 576.17 503.66 1505.66

### For copying to Word version of tables Highlight num bers portion of table here, copy; then goto Word, highlight num bers section of its table, paste

Filterable PM10 Condensable PM10 (CPM) Filterable PM H2SO4 NH3 PM coarse PM fine soil PM fine

EC inorganic

(SO4) organic

(SOA) Max Stack

Test lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu
0.0019 0 0.010 0.007 0.00028 0.0019 0.0040 0.026

0.0019 0 0.008 0.006 0.00023 0.0019 0.0040 0.021

0.0019 0 0.012 0.009 0.00033 0.0019 0.0040 0.031

Filterable PM10 Condensable PM10 (CPM) 

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals H2SO4 NH3 PM coarse PM fine soil PM fine

EC inorganic

(SO4) organic

(SOA) Max Stack

Testlb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr scen SRCNAM **SO2 SO4**  **NOX**

16.70 0 86.89 63.86 2.45 16.35 35.18 228.66 f1 **NGS1** 487.75 16.35 483.71 16.70 0 75.20 55.27 2.12 17.52 37.69 197.89 f1 **NGS2** 526.92 17.52 518.29 16.70 0 107.87 79.28 3.05 17.03 36.63 283.88 f1 **NGS3** 576.17 17.03 503.66

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals**HNO3 NO3**  **SOA PM**  **F PM**  **C EC** 

0 0 35.18 63.86 86.89 2.45 0 0 37.69 55.27 75.20 2.12 0 0 36.63 79.28 107.87 3.05**f2: LNB on #1,3; close #2** Filterable PM10 Condensable PM10 (CPM) Filterable PM SO2 NOx H2SO4 NH3 PM coarse PM fine soil PM fine

EC inorganic

(SO4) organic

(SOA) Max Stack

Test lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu
0.06 0.24 0.00027 0 0.010 0.007 0.00028 0.00026 0.0040 0.026

0.00 0.00 0.00000 0 0.000 0.000 0.00000 0.00000 0.0000 0.000

0.06 0.24 0.00027 0 0.012 0.009 0.00033 0.00026 0.0040 0.031

Filterable PM10 Condensable PM10 (CPM) Filterable PM 

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals SO2 NOx H2SO4 NH3 PM coarse PM fine PM fine inorganic organic Max Stack lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr scen SRCNAM **SO2 SO4**  **NOX HNO3**  **NO3 SOA**  **PMF PMC**  **EC** 487.75 2110.74 2.37 0 86.89 63.86 2.45 2.32 35.18 228.66 f2 **NGS1** 487.75 2.32 2110.74 0 0 35.18 63.86 86.89 2.45 0.00 0.00 0.00 0 0.00 0.00 0.00 0.00 0.00 0.00 f2 **NGS2** 0.00 0.00 0.00 0 0 0.00 0.00 0.00 0.00 576.17 2197.78 2.47 0 107.87 79.28 3.05 2.42 36.63 283.88 f2 **NGS3** 576.17 2.42 2197.78 0 0 36.63 79.28 107.87 3.05

09000064817e49bb f2 TW GA1-2020 7/28/2014**f3: SCR on #1,3; close #2** Filterable PM10 Condensable PM10 (CPM) Filterable PM Max Heat Input SO2 NOx H2SO4 NH3 PM coarse PM fine soil PM fine

EC inorganic

(SO4) organic

(SOA) Max Stack

Test MMBtu/hr lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu
Unit 1 8,795 0.06 0.07 0.0019 0 0.010 0.007 0.00028 0.0019 0.0040 0.026

Unit 2 0 0.00 0.00 0.0000 0 0.000 0.000 0.00000 0.0000 0.0000 0.000

Unit 3 9,157 0.06 0.07 0.0019 0 0.012 0.009 0.00033 0.0019 0.0040 0.031
Filterable PM10 Condensable PM10 (CPM) 

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals Max Heat Input SO2 NOx H2SO4 NH3 PM coarse PM fine soil PM fine

EC inorganic

(SO4) organic

(SOA) Max Stack

Test MMBtu/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr scen Unit 1 8,795 487.75 615.63 16.70 0 86.89 63.86 2.45 16.35 35.18 228.66 f3 Unit 2 0 0.00 0.00 0.00 0 0.00 0.00 0.00 0.00 0.00 0.00 f3 Unit 3 9,157 576.17 641.02 17.39 0 107.87 79.28 3.05 17.03 36.63 283.88 f3

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals

SRCNAM **SO2 SO4**  **NOX HNO3**  **NO3 SOA**  **PMF PMC**  **EC NGS1**  487.75 16.35 615.63 0 0 35.18 63.86 86.89 2.45 **NGS2** 0.00 0.00 0.00 0 0 0.00 0.00 0.00 0.00 **NGS3** 576.17 17.03 641.02 0 0 36.63 79.28 107.87 3.05**EPA revisions to values used in A** **NPRM**

MMBtu/day MMBtu/hr % ton/day lb/hr Navajo 1 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, **LNB** , SOFA, hot side ESP, wet FGD **237,669** 9,903 0.593 **6.59** 549.21

Navajo 2 Close Unit

Navajo 3 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, **LNB** , SOFA, hot side ESP, wet FGD **247,470** 10,311 0.593 **7.79** 648.76 

### ** Below**are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately** (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or ma lfunction. (d) Maximum daily

/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. (e) Maximum of 6 stack test results for the 2001 to 2006 period. (a) Maximum daily

24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02. Facility Unit Description Maximum Heat Input (a) Maximum Sulfur Content (b) Maximum SO2 Emissions 

## f4: Close one unit, increase capacity **on remaining tw o unit by**  **total of 189 MW (net), LNB+SOFA on remaining tw** **o units**

(f) For a dry

bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (h) Total condensable PM10 is the sum of H2SO4 and organic condensible PM10 emissions. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. EPRI (2008) Eqn 4-2b indicates that 95% of fuel sulfur is converted to SO2. (j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998.

### EPA

**Revisions for Final Rule** (1) Close Unit 2 because this is the unit with the most space congestion (for SCR installation) due to coal conveyor (2) increase capacity

on remaining two units equally by 189 MW(net) total (or 94.5 MWnet increase on each unit). A 94.5 MWnet increase = 844.5 net capacity = 1.126 higher than 750 MW . Therefore, increase max heat input by factor of 1.126 (3) increase daily

SO2 emissions also by 1.126 (3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for PRB coal (strongly

alkaline coal) 

### EPA revisions to Values used in ANPRM (3-7-11) (1) set HCl and HF to zero (2) in sulfuric acid calculation, revised penetration factor for hot-side ESP from 1 (used in ANPRM) to 0.63.lb/MMBtu % reduction ton/day lb/hr lb/MMBtu lb/MMBtu (e) lb/hr lb/hr

0.055 44% 28.52 2,376.69 0.240 0.0260 257.48 172.51 (f)

0.063 41% 29.70 2,474.70 0.240 0.0310 319.65 214.16 (f) 

### ** Below**are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately** (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or (d) Maximum daily

/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. (a) Maximum daily

24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02. Maximum SO2 Emissions (c) Maximum NOx Emissions (d) 

## Maximum Emissions Including Speciated PM **10**

## Emissions

**Navajo Units 1, 2, and 3 f4: Close one unit, increase capacity**  **on remaining tw o unit by**  **total of 189 MW (net), LNB+SOFA on remaining tw** **o units**
Maximum Filterable PM Em issions total

(f) For a dry

bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. (j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998.(1) Close Unit 2 because this is the unit with the most space congestion (for SCR installation) due to coal conveyor (2) increase capacity

on remaining two units equally by 189 MW(net) total (or 94.5 MWnet increase on each unit). A 94.5 MWnet increase = 844.5 net capacity = 1.126 higher than 750 MW . Therefore, increase max heat input by factor of 1.126 (3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 forfine total fine soil EC

lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr 97.84 (f) 74.67 (f) 71.9 (g) 2.76 (g) 42.28 (h) 2.67 (i) 2.62 39.61 (j)

121.47 (f) 92.70 (f) 89.3 (g) 3.43 (g) 44.03 (h) 2.78 (i) 2.73 41.25 (j)

(c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or 

## f4: Close one unit, increase capacity **on remaining tw o unit by**  **total of 189 MW (net), LNB+SOFA on remaining tw** **o units** Condensable PM 10 organic

Filterable PM 10 coarse Fine total H2SO4 SO4

(g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47.(2) increase capacity on remaining two units equally by 189 MW(net) total (or 94.5 MWnet increase on each unit). A 94.5 MWnet increase = 844.5 net capacity = 1.126 higher than 750 MW . Therefore, increase max heat input by factor of 1.126 (3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 forH2SO4 HCl HF HCl + HF HCl+HF+ Pmfine HCl+HF+

Pmfine EC lb/hr lb/m mbtu lb/m mbtu lb/Mm btu lb/hr new PM fine lb/m mbtu lb/m mbtu
214.79 0.00027 0 0 0.00 71.91 0.007 0.00028

258.19 0.00027 0 0 0.00 89.27 0.009 0.00033 Total PM 10

### For copying to Word version of tables Highlight num bers portion of table here, copy; then in Word, highlight num bers section of its table, paste **f4: LNB on #1,3 w/incr capy; close #2** coarse SO4 organic Max Heat Input lb/m mbtu lb/m mbtu lb/m mbtu MMBtu/hr
0.010 0.00026 0.0040 Unit 1 9,903

Unit 2 0

0.012 0.00026 0.0040 Unit 3 10,311

Max Heat MMBtu/hr Unit 1 9,903 Unit 2 0 Unit 3 10,311

### For copying to Word version of tables Highlight num bers portion of table here, copy; then in Word, highlight num bers section of its table, paste **f4: LNB on #1,3 w/incr capy; close #2** Filterable PM10 Condensable PM10 (CPM) Filterable PM SO2 NOx H2SO4 NH3 PM coarse PM fine soil PM fine

EC inorganic

(SO4) organic

(SOA) Max Stack

Test lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu
0.06 0.24 0.00027 0 0.010 0.007 0.00028 0.00026 0.0040 0.026

0.00 0.00 0.00000 0 0.000 0.000 0.00000 0.00000 0.0000 0.000

0.06 0.24 0.00027 0 0.012 0.009 0.00033 0.00026 0.0040 0.031

Filterable PM10 Condensable PM10 (CPM) Filterable PM SO2 NOx H2SO4 NH3 PM coarse PM fine PM fine inorganic organic Max Stack lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr 549.21 2376.69 2.67 0 97.84 71.91 2.76 2.62 39.61 257.48 0.00 0.00 0.00 0 0.00 0.00 0.00 0.00 0.00 0.00 648.76 2474.70 2.78 0 121.47 89.27 3.43 2.73 41.25 319.65Filterable PM

Filterable PM 

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals scen SRCNAM **SO2 SO4**  **NOX HNO3**  **NO3 SOA**  **PM F**  f4 **NGS1** 549.21 2.62 2376.69 0 0 39.61 71.91 f4 **NGS2** 0.00 0.00 0.00 0 0 0.00 0.00 f4 **NGS3** 648.76 2.73 2474.70 0 0 41.25 89.27**PM C**  **EC**

97.84 2.76 0.00 0.00 121.47 3.43**EPA revisions to values used in Proposed Rule** 

MMBtu/day MMBtu/hr % ton/day lb/hr Navajo 1 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, LNB, SOFA, **SCR**, hot side ESP, wet FGD **237,669** 9,903 0.593 **6.59** 549.21

Navajo 2 Close Unit

Navajo 3 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, LNB, SOFA, **SCR**, hot side ESP, wet FGD **247,470** 10,311 0.593 **7.79** 648.76

Unit conversion for ammonia slip from ppmvd to lb/hr NH3 0.75 ppmvd at 6% O2 Facility Unit Description Maximum Heat Input (a) Maximum Sulfur Content (b) Maximum SO2 Emissions

(b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or malfunction. (d) Maximum daily

/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. (e) Maximum of 6 stack test results for the 2001 to 2006 period. 

### f5: Close one unit, increase net capacity **of remaining tw o units by**  **total of 189 MW, operate remaining tw o units w** **ith SCR+LNB+SOFA (0.07)** 

(l) Ammonia is assumed to react with SO4 to form ammonium sulfate per EPRI 2008 if the molecules of NH3 are at least twice those of H2SO4; otherwise, ammonium bisulfate is formed. (f) For a dry

bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (h) Total condensable PM10 is the sum of H2SO4 and organic condensable PM10 emissions. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. EPRI (2008) Eqn 4-2b indicates that 95% of fuel sulfur is converted to SO2. (j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998. (k) Ammonia slip is 0.75 ppmvd at 6% O2 for SCR. 

### ** Below**are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately** (a) Maximum daily

24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02.0.00045 lb/MMBtu unit 1 4.49 lb/hr unit 2 0.00 lb/hr unit 3 4.68 lb/hr

(6) The 0.63 ESP penetration is applied to H2SO4 before the ammonia reaction, which mainly occurs in the lower temperatures of the air preheater. SCR conversion of SO2 to SO3 99.50% = fraction SO2 remaining after 3 layers, corresponding to 0.5% conversion layers conversion

1 0.17% 2 0.33% 3 0.50% 4 0.67% 

### EPA **Revisions for Final Rule** (1) Close Unit 2 because this is the unit with the most space congestion (for SCR installation) due to coal conveyor (2) increase capacity

on remaining two units equally by 189 MW(net) total (or 94.5 MWnet increase on each unit). A 94.5 MWnet increase = 844.5 net capacity = 1.126 higher than 750 MW . Therefore, increase max heat input by factor of 1.126 (3) increase daily

SO2 emissions also by 1.126

Penetration factors H2SO4 AbS and AS PM, general p % ctrl p % ctrl p hot-side ESP 0.63 37% 0.01 99% 0.01 Air Preheater 0.50 50% 0.75 25% Wet FGD (scrubber) 0.47 53% 0.50 50% EPRI H2SO4 doc EPRI NH3 doc (5) Ammonia slip calculation only affects split between H2SO4 and ammonium sulfate/bisulfate. Since in this case there is no ammonia slip, and controls are assumed to affect all these the same way, the split is irrelevant, and only total am ount of SO4 matters for modeling. (Since all SO4 forms are assumed to be affected the same way, the SO4 for modeling can also be calculated directly from H2SO4 * 96.06/98.08.) 

### EPA revisions to Values used in ANPRM (3-7-11) (1) set HCl and HF to zero (2) in sulfuric acid calculation, revised penetration factor for hot-side ESP from 1 (used in ANPRM) to 0.63. (3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for PRB coal (strongly alkaline coal) (4) 0.67% SO2 to SO3 conversion efficiency : Three layers give 0.5% conversion; may not have 4th till 3rd year, but conservatively assume all in four place at start. 1 - (1 - 0.005)^(3/4) or 0.005*4/3 are both about 0.0067 = 0.67%, see belowlb/MMBtu % reduction ton/day lb/hr lb/MMBtu lb/MMBtu (e) lb/hr lb/hr

0.055 84% 8.32 693.20 **0.070** 0.026 257.48 172.51 (f)

0.063 83% 8.66 721.79 **0.070** 0.031 319.65 214.16 (f)

Method 19 (SO2 removal efficiency) formula, Eq. 19-1: 

## Maximum Emissions Including Speciated PM **10**

## Emissions

**Navajo Units 1, 2, and 3**

Maximum SO2 Emissions (c) Maximum NOx Emissions (d) total

(b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or malfunction. (d) Maximum daily

/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. Maximum Filterable PM Em issions 

### f5: Close one unit, increase net capacity **of remaining tw o units by**  **total of 189 MW, operate remaining tw o units w** **ith SCR+LNB+SOFA (0.07)** 

(l) Ammonia is assumed to react with SO4 to form ammonium sulfate per EPRI 2008 if the molecules of NH3 are at least twice those of H2SO4; otherwise, ammonium bisulfate is formed. (f) For a dry

bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. (j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998. 

### ** Below**are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately** (a) Maximum daily

24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02.E = Cd*Fd*20.9/(20.9 - %O2d) Atm osphere is 20.9% oxygen

Cd = Pollutant concentration, dry basis Am monia M.W . is 17 lb/lb.mol Fd = volum es of combustion components per unit of heat content 385 ft3/lb-mol = volume of 1 ft3 of gas at STP %O2d = Concentration of oxygen on a dry basis, percent. Table 19-2 gives F factor for bituminous coal as Fd = 9780 sdcf/10^6 Btu

(6) The 0.63 ESP penetration is applied to H2SO4 before the ammonia reaction, which mainly occurs in the lower temperatures of the air preheater. = fraction SO2 remaining after 3 layers, corresponding to 0.5% conversion

(1) Close Unit 2 because this is the unit with the most space congestion (for SCR installation) due to coal conveyor (2) increase capacity

on remaining two units equally by 189 MW(net) total (or 94.5 MWnet increase on each unit). A 94.5 MWnet increase = 844.5 net capacity = 1.126 higher than 750 MW . Therefore, increase max heat input by factor of 1.126

% ctrl 99% (5) Ammonia slip calculation only affects split between H2SO4 and ammonium sulfate/bisulfate. Since in this case there is no ammonia slip, and controls are assumed to affect all these the same way, the split is irrelevant, and only total am ount of SO4 matters for modeling. (Since all SO4 forms are assumed to be (3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for PRB coal (4) 0.67% SO2 to SO3 conversion efficiency : Three layers give 0.5% conversion; may not have 4th till 3rd year, but conservatively assume all in four place at start. 1 - (1 - 0.005)^(3/4) or 0.005*4/3 are both about 0.0067 = 0.67%, see belowfine total fine soil EC

lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr 97.84 (f) 74.67 (f) 71.9 (g) 2.76 (g) 58.41 (h) 18.80 (i) 18.42 39.61 (j)

121.47 (f) 92.70 (f) 89.3 (g) 3.43 (g) 60.82 (h) 19.58 (i) 19.18 41.25 (j) SO4 coarse Fine total H2SO4 organic Filterable PM 10

(c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or malfunction. Condensable PM 10 

### f5: Close one unit, increase net capacity **of remaining tw o units by**  **total of 189 MW, operate remaining tw o units w** **ith SCR+LNB+SOFA (0.07)** 

(g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47.Atm osphere is 20.9% oxygen Am monia M.W . is 17 lb/lb.mol 385 ft3/lb-mol = volume of 1 ft3 of gas at STP

(2) increase capacity

on remaining two units equally by 189 MW(net) total (or 94.5 MWnet increase on each unit). A 94.5 MWnet increase = 844.5 net capacity = 1.126 higher than 750 MW . Therefore, increase max heat input by factor of 1.126 (5) Ammonia slip calculation only affects split between H2SO4 and ammonium sulfate/bisulfate. Since in this case there is no ammonia slip, and controls are assumed to affect all these the same way, the split is irrelevant, and only total am ount of SO4 matters for modeling. (Since all SO4 forms are assumed to be (3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for PRB coal (4) 0.67% SO2 to SO3 conversion efficiency : Three layers give 0.5% conversion; may not have 4th till 3rd year, but conservatively assume all in four place at start. 1 - (1 - 0.005)^(3/4) or 0.005*4/3 are both about 0.0067 = 0.67%, see belowlb/hr lb/hr lb m ole/hr lb m ole/hr mole ratio lb m ole/hr lb m ole/hr lb m ole/hr

80.01 4.49 (k) 0.264 0.816 0.323 0.552 0.264 0.000

83.31 4.68 (k) 0.275 0.849 0.323 0.575 0.275 0.000 Am monia slip and reaction with sulfuric acid, for Net ammonia slip and Modeling SO4 [H2SO4] [NH3] /

[H2SO4] ratio [H2SO4]

after reaction [AbS] or

[NH4HSO4] after reaction [AS] or

[(NH4)2SO 4] after reaction

(c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or malfunction. H2SO4 before NH3 interaction, after ESP NH3 Slip [NH3]H2SO4 HCl HF HCl + HF

lb m ole/hr lb/hr lb/hr lb/hr lb/hr lb/m mbtu lb/m mbtu lb/Mm btu lb/hr
0.000 **0.00** 19.86 **18.41 231.98**  **0.0019** 0 0 0

0.000 **0.00** 20.68 **19.17** 276.086 **0.0019** 0 0 0 Am monia slip and reaction with sulfuric acid, for Net ammonia slip and Modeling SO4 H2SO4 + AbS + AS post-control Total

Effective SO4 for modeling Total PM10 [NH3] after reaction Net NH3

after reaction & WFGD

### For copying to Word version of tables Highlight num bers portion of table here, copy; then goto Word, highlight num bers section of its table, paste **f5: SCR on #1,#3 w/incr capy; close #2** Filterable PM10 HCl+HF+ Pmfine Max Heat Input SO2 NOx H2SO4 NH3 PM coarse new PM fine MMBtu/hr lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu
71.91 Unit 1 9,903 0.06 0.07 0.0019 0 0.010

Unit 2 0 0.00 0.00 0.0000 0 0.000

89.27 Unit 3 10,311 0.06 0.07 0.0019 0 0.012

Filterable PM10 Max Heat Input SO2 NOx H2SO4 NH3 PM coarse MMBtu/hr lb/hr lb/hr lb/hr lb/hr lb/hr Unit 1 9,903 549.21 693.20 18.80 0 97.84 Unit 2 0 0.00 0.00 0.00 0 0.00 Unit 3 10,311 648.76 721.79 19.58 0 121.47 1414.99Highlight num bers portion of table here, copy; then goto Word, highlight num bers section of its table, paste

Filterable PM10 Condensable PM10 (CPM) Filterable PM PM fine soil PM fine

EC inorganic

(SO4) organic

(SOA) Max Stack

Test lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu
0.007 0.00028 0.0019 0.0040 0.026

0.000 0.00000 0.0000 0.0000 0.000

0.009 0.00033 0.0019 0.0040 0.031

Filterable PM10 Condensable PM10 (CPM) 

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals

PM fine soil PM fine

EC inorganic

(SO4) organic

(SOA) Max Stack

Test lb/hr lb/hr lb/hr lb/hr lb/hr scen SRCNAM **SO2 SO4**  71.91 2.76 18.41 39.61 257.48 f5 **NGS1** 549.21 18.41 0.00 0.00 0.00 0.00 0.00 f5 **NGS2** 0.00 0.00 89.27 3.43 19.17 41.25 319.65 f5 **NGS3** 648.76 19.17

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals

**NOX HNO3**  **NO3 SOA**  **PM F**  **PM C**  **EC** 693.20 0 0 39.61 71.91 97.84 2.76 0.00 0 0 0.00 0.00 0.00 0.00 721.79 0 0 41.25 89.27 121.47 3.43**EPA revisions to values used in A** **NPRM**

MMBtu/day MMBtu/hr % ton/day lb/hr Navajo 1 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, **LNB** , SOFA, hot side ESP, wet FGD 211,074 8,795 0.593 5.85 487.75

Navajo 2 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, **LNB** , SOFA, hot side ESP, wet FGD **56,993** 2,375 0.593 **1.59** 132.78

Navajo 3 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, **LNB** , SOFA, hot side ESP, wet FGD 219,778 9,157 0.593 6.91 576.17

(e) Maximum of 6 stack test results for the 2001 to 2006 period. (f) For a dry

bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (h) Total condensable PM10 is the sum of H2SO4 and organic condensible PM10 emissions. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. EPRI (2008) Eqn 4-2b indicates that 95% of fuel sulfur is converted to SO2. (j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998. 

### ** Below**are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately** (a) Maximum daily

24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02. (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or ma lfunction. (d) Maximum daily

/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. 

## f6: Reduce net capacity **on all 3 units by**

**561 MW total, operate w ith LNB+SOFA** 
Facility Unit Description Maximum Heat Input (a) Maximum Sulfur Content (b) Maximum SO2 Emissions

### EPA

**Revisions for Final Rule** (1) Decrease total net capacity of Unit 2 by

561 MW . 189 MWis 0.252 of 750 MW . (2) decrease daily

SO2 emissions by

factor of 0.252 (2) in sulfuric acid calculation, revised penetration factor for hot-side ESP from 1 (used in ANPRM) to 0.63. (3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for PRB coal (strongly

alkaline coal) 

### EPA revisions to Values used in ANPRM (3-7-11) (1) set HCl and HF to zerolb/MMBtu % reduction ton/day lb/hr lb/MMBtu lb/MMBtu (e) lb/hr lb/hr

0.055 51% 25.33 2,110.74 0.240 0.0260 228.66 153.20 (f)

0.056 86% 6.84 569.93 0.240 0.0210 49.87 33.41 (f)

0.063 47% 26.37 2,197.78 0.240 0.0310 283.88 190.20 (f)

(f) For a dry

bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. (j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998. 

### ** Below**are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately** (a) Maximum daily

24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02. (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or (d) Maximum daily

/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. Maximum Filterable PM Em issions total 

## Maximum Emissions Including Speciated PM **10**

## Emissions

**Navajo Units 1, 2, and 3 f6: Reduce net capacity**  **on all 3 units by**

**561 MW total, operate w ith LNB+SOFA** 
Maximum SO2 Emissions (c) Maximum NOx Emissions (d)(3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 forfine total fine soil EC

lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr 86.89 (f) 66.31 (f) 63.9 (g) 2.45 (g) 37.55 (h) 2.37 (i) 2.32 35.18 (j)

18.95 (f) 14.46 (f) 13.9 (g) 0.54 (g) 10.14 (h) 0.64 (i) 0.63 9.50 (j)

107.87 (f) 82.33 (f) 79.3 (g) 3.05 (g) 39.10 (h) 2.47 (i) 2.42 36.63 (j)

(g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. organic

(c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or Filterable PM 10 Condensable PM 10 coarse Fine total H2SO4 SO4 

## f6: Reduce net capacity **on all 3 units by**

**561 MW total, operate w ith LNB+SOFA** (3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 forH2SO4 HCl HF HCl + HF HCl+HF+ Pmfine HCl+HF+

Pmfine EC lb/hr lb/m mbtu lb/m mbtu lb/Mm btu lb/hr new PM fine lb/m mbtu lb/m mbtu
190.76 0.00027 0 0 0.00 63.86 0.007 0.00028

43.55 0.00027 0 0 0.00 13.93 0.006 0.00023

229.30 0.00027 0 0 0.00 79.28 0.009 0.00033 Total PM 10

### For copying to Word version of tables Highlight num bers portion of table here, copy; then in Word, highlight num bers section of its table, paste
**f6: LNB+SOFA**

**on #1,2,3; reduce capy by 561 MW** coarse SO4 organic Max Heat Input lb/m mbtu lb/m mbtu lb/m mbtu MMBtu/hr
0.010 0.00026 0.0040 Unit 1 8,795

0.008 0.00026 0.0040 Unit 2 2,375

0.012 0.00026 0.0040 Unit 3 9,157

Max Heat MMBtu/hr Unit 1 8,795 Unit 2 2,375 Unit 3 9,157

### For copying to Word version of tables Highlight num bers portion of table here, copy; then in Word, highlight num bers section of its table, paste
**f6: LNB+SOFA**

**on #1,2,3; reduce capy by 561 MW** Filterable PM10 Condensable PM10 (CPM) Filterable PM SO2 NOx H2SO4 NH3 PM coarse PM fine soil PM fine

EC inorganic

(SO4) organic

(SOA) Max Stack

Test lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu
0.06 0.24 0.00027 0 0.010 0.007 0.00028 0.00026 0.0040 0.026

0.06 0.24 0.00027 0 0.008 0.006 0.00023 0.00026 0.0040 0.021

0.06 0.24 0.00027 0 0.012 0.009 0.00033 0.00026 0.0040 0.031

Filterable PM10 Condensable PM10 (CPM) Filterable PM SO2 NOx H2SO4 NH3 PM coarse PM fine PM fine inorganic organic Max Stack lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr 487.75 2110.74 2.37 0 86.89 63.86 2.45 2.32 35.18 228.66 132.78 569.93 0.64 0 18.95 13.93 0.54 0.63 9.50 49.87 576.17 2197.78 2.47 0 107.87 79.28 3.05 2.42 36.63 283.88Filterable PM

Filterable PM 

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals scen SRCNAM **SO2 SO4**  **NOX HNO3**  **NO3 SOA**  **PM F**  f6 **NGS1** 487.75 2.32 2110.74 0 0 35.18 63.86 f6 **NGS2** 132.78 0.63 569.93 0 0 9.50 13.93 f6 **NGS3** 576.17 2.42 2197.78 0 0 36.63 79.28**PM C**  **EC**

86.89 2.45 18.95 0.54 107.87 3.05**EPA revisions to values used in Proposed Rule** 

MMBtu/day MMBtu/hr % ton/day lb/hr Navajo 1 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, LNB, SOFA, **SCR**, hot side ESP, wet FGD 211,074 8,795 0.593 5.85 487.75

Navajo 2 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, **LNB** , SOFA, hot side ESP, wet FGD **56,993** 2,375 0.593 **1.59** 132.78

Navajo 3 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, LNB, SOFA, **SCR**, hot side ESP, wet FGD 219,778 9,157 0.593 6.91 576.17

(d) Maximum daily

/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. (e) Maximum of 6 stack test results for the 2001 to 2006 period. (f) For a dry

bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. EPRI (2008) Eqn 4-2b indicates that 95% of fuel sulfur is converted to SO2. (j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998. 

### ** Below**are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately** (a) Maximum daily

24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02. (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or ma lfunction. (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (h) Total condensable PM10 is the sum of H2SO4 and organic condensible PM10 emissions. 

## f7: Reduce net capacity **on Unit 2 by**

**561 MW operate w ith LNB+SOFA**  **on Unit 2, install SCR+LNB+SOFA on 2 units** 
Facility Unit Description Maximum Heat Input (a) Maximum Sulfur Content (b) Maximum SO2 Emissions

### EPA

**Revisions for Final Rule** (1) Decrease total net capacity on Unit 2 by

561 MW . (decrease max daily heat input by

factor of 0.252 for unit2) (2) install and operate SCR on the two units still at full capacity (3) decrease daily

SO2 emissions by

factor of 0.252 on unit 2 (3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for PRB coal (strongly

alkaline coal) 

### EPA revisions to Values used in ANPRM (3-7-11) (1) set HCl and HF to zero (2) in sulfuric acid calculation, revised penetration factor for hot-side ESP from 1 (used in ANPRM) to 0.63.lb/MMBtu % reduction ton/day lb/hr lb/MMBtu lb/MMBtu (e) lb/hr lb/hr

0.055 86% 7.39 615.63 **0.070** 0.0260 228.66 153.20 (f)

0.056 86% 6.84 569.93 **0.240** 0.0210 49.87 33.41 (f)

0.063 85% 7.69 641.02 **0.070** 0.0310 283.88 190.20 (f)

(d) Maximum daily

/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. Maximum Filterable PM Em issions

(f) For a dry

bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. (j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998. 

### ** Below**are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately** (a) Maximum daily

24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02. (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. 

## Maximum Emissions Including Speciated PM **f7: Reduce net capacity on Unit 2 by** 

**561 MW operate w ith LNB+SOFA**  **on Unit 2, install SCR+LNB+SOFA on 2 units** 
Maximum SO2 Emissions (c) Maximum NOx Emissions (d) total(1) Decrease total net capacity on Unit 2 by

561 MW . (decrease max daily heat input by

factor of 0.252 for unit2) (3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 forfine total fine soil EC

lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr 86.89 (f) 66.31 (f) 63.9 (g) 2.45 (g) 51.88 (h) 16.70 (i) 16.36 35.18 (j)

18.95 (f) 14.46 (f) 13.9 (g) 0.54 (g) 10.14 (h) 0.64 (i) 0.63 9.50 (j)

107.87 (f) 82.33 (f) 79.3 (g) 3.05 (g) 54.02 (h) 17.39 (i) 17.03 36.63 (j)

Filterable PM 10 Condensable PM 10

(i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. organic

(c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. SO4 

## Maximum Emissions Including Speciated PM **10**

## Emissions

**Navajo Units 1, 2, and 3 f7: Reduce net capacity**  **on Unit 2 by**

**561 MW operate w ith LNB+SOFA**  **on Unit 2, install SCR+LNB+SOFA on 2 units** 

coarse Fine total H2SO4(3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 forlb/hr lb/hr lb m ole/hr lb m ole/hr mole ratio lb m ole/hr lb m ole/hr lb m ole/hr

71.06 0.00 (k) 0.000 0.724 0.000 0.724 0.000 0.000

2.73

73.99 0.00 (k) 0.000 0.754 0.000 0.754 0.000 0.000 H2SO4 before NH3 interaction, after ESP NH3 Slip [NH3] [H2SO4] [NH3] / [H2SO4] ratio [H2SO4]

after reaction [AbS] or

[NH4HSO4] after reaction [AS] or

[(NH4)2SO 4] after reactionH2SO4 HCl HF HCl + HF

lb m ole/hr lb/hr lb/hr lb/hr lb/hr lb/m mbtu lb/m mbtu lb/Mm btu lb/hr
0.000 **0.00** 16.70 **16.35** 205.08 0.00190 0 0 0.00

**0.63** 43.55 0.00027 0 0 0.00

0.000 **0.00** 17.39 **17.03** 244.22 0.00190 0 0 0.00

Net NH3 after reaction & WFGD H2SO4 +

AbS + AS post-control Total

Effective SO4 for modeling Total PM10 [NH3] after reactionHCl+HF+

Pmfine HCl+HF+

Pmfine EC coarse SO4 organic new PM fine lb/m mbtu lb/m mbtu lb/m mbtu lb/m mbtu lb/m mbtu
63.86 0.007 0.00028 0.010 0.00186 0.0040

13.93 0.006 0.00023 0.008 0.00026 0.0040

79.28 0.009 0.00033 0.012 0.00186 0.0040

### For copying to Word version of tables Highlight num bers portion of table here, copy; then in Word, highlight num bers section of its table, paste **f7: SCR on #1,#3; LNB+SOFA on #2; reduce capy by 561 MW**  Filterable PM10 Max Heat Input SO2 NOx H2SO4 NH3 PM coarse PM fine soil MMBtu/hr lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu
Unit 1 8,795 0.06 0.07 0.00190 0 0.010 0.007

Unit 2 2,375 0.06 0.24 0.00027 0 0.008 0.006

Unit 3 9,157 0.06 0.07 0.00190 0 0.012 0.009

Filterable PM10 Max Heat SO2 NOx H2SO4 NH3 PM coarse PM fine MMBtu/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr Unit 1 8,795 487.75 615.63 16.70 0 86.89 63.86 Unit 2 2,375 132.78 569.93 0.64 0 18.95 13.93 Unit 3 9,157 576.17 641.02 17.39 0 107.87 79.28Highlight num bers portion of table here, copy; then in Word, highlight num bers section of its table, paste
Condensable PM10 (CPM) Filterable PM PM fine EC inorganic

(SO4) organic

(SOA) Max Stack

Test lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu
0.00028 0.00186 0.0040 0.026

0.00023 0.00026 0.0040 0.021

0.00033 0.00186 0.0040 0.031

Condensable PM10 (CPM) Filterable PM 

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals PM fine inorganic organic Max Stack lb/hr lb/hr lb/hr lb/hr scen SRCNAM **SO2 SO4**  **NOX** 2.45 16.36 35.18 228.66 f7 **NGS1** 487.75 16.36 615.63 0.54 0.63 9.50 49.87 f7 **NGS2** 132.78 0.63 569.93 3.05 17.03 36.63 283.88 f7 **NGS3** 576.17 17.03 641.02

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals

**HNO3 NO3**  **SOA PM**  **F PM**  **C EC**  0 0 35.18 63.86 86.89 2.45 0 0 9.50 13.93 18.95 0.54 0 0 36.63 79.28 107.87 3.05**EPA revisions to values used in Proposed Rule** 

MMBtu/day MMBtu/hr % ton/day lb/hr Navajo 1 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, **LNB** , SOFA, hot side ESP, wet FGD **158,306** 6,596 0.593 **4.39** 365.81

Navajo 2 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, **LNB** , SOFA, hot side ESP, wet FGD **169,622** 7,068 0.593 **4.74** 395.19

Navajo 3 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, **LNB** , SOFA, hot side ESP, wet FGD **164,834** 6,868 0.593 **5.19** 432.13 

### ** Below**are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately** (a) Maximum daily

24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02. (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or ma lfunction. (d) Maximum daily

/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. (f) For a dry

bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (h) Total condensable PM10 is the sum of H2SO4 and organic condensible PM10 emissions. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. EPRI (2008) Eqn 4-2b indicates that 95% of fuel sulfur is converted to SO2. (j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998. (e) Maximum of 6 stack test results for the 2001 to 2006 period. 

## f8: Reduce net capacity **on equally**

**on 3 units by**

**561 MW operate w ith LNB+SOFA**  **on Unit 2, install SCR+LNB+SOFA on 2 units** 
Facility Unit Description Maximum Heat Input (a) Maximum Sulfur Content (b) Maximum SO2 Emissions

### EPA

**Revisions for Final Rule** (1) Decrease total net capacity on all 3 units equally

by 561 MW . (i.e., apply

factor of 0.75 to daily

heat input for each unit - from 1-(561/2250)) (2) install and operate SCR on the two units still at full capacity (3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for PRB coal (strongly

alkaline coal) 

### EPA revisions to Values used in ANPRM (3-7-11) (1) set HCl and HF to zero (2) in sulfuric acid calculation, revised penetration factor for hot-side ESP from 1 (used in ANPRM) to 0.63.lb/MMBtu % reduction ton/day lb/hr lb/MMBtu lb/MMBtu (e) lb/hr lb/hr

0.055 89% 5.54 461.72 **0.070** 0.0260 171.50 114.90 (f)

0.056 60% 20.35 1,696.22 **0.240** 0.0210 148.42 99.44 (f)

0.063 89% 5.77 480.76 **0.070** 0.0310 212.91 142.65 (f) 

### ** Below**are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately** (a) Maximum daily

24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02. (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or (d) Maximum daily

/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. (f) For a dry

bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. (j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998. total 

## Maximum Emissions Including Speciated PM **f8: Reduce net capacity on equally** 

**on 3 units by**

**561 MW operate w ith LNB+SOFA**  **on Unit 2, install SCR+LNB+SOFA on 2 units** 
Maximum SO2 Emissions (c) Maximum NOx Emissions (d) Maximum Filterable PM Em issions(1) Decrease total net capacity on all 3 units equally

by 561 MW . (i.e., apply

factor of 0.75 to daily

heat input for each unit - from 1-(561/2250)) (3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 forfine total fine soil EC

lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr 65.17 (f) 49.73 (f) 47.9 (g) 1.84 (g) 38.91 (h) 12.52 (i) 12.27 26.38 (j)

56.40 (f) 43.04 (f) 41.4 (g) 1.59 (g) 30.18 (h) 1.91 (i) 1.87 28.27 (j)

80.91 (f) 61.74 (f) 59.5 (g) 2.28 (g) 40.51 (h) 13.04 (i) 12.77 27.47 (j)

(c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. coarse Fine total H2SO4 SO4 organic 

## Maximum Emissions Including Speciated PM **10**

## Emissions

**Navajo Units 1, 2, and 3 f8: Reduce net capacity**  **on equally**

**on 3 units by**

**561 MW operate w ith LNB+SOFA**  **on Unit 2, install SCR+LNB+SOFA on 2 units**  Filterable PM 10 Condensable PM 10(3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 forlb/hr lb/hr lb m ole/hr lb m ole/hr mole ratio lb m ole/hr lb m ole/hr lb m ole/hr

53.29 0.00 (k) 0.000 0.543 0.000 0.543 0.000 0.000

8.12

55.49 0.00 (k) 0.000 0.566 0.000 0.566 0.000 0.000 [AS] or [(NH4)2SO 4] after reaction [H2SO4] [NH3] /

[H2SO4] ratio [H2SO4]

after reaction [AbS] or

[NH4HSO4] after reaction NH3 Slip [NH3] H2SO4 before NH3 interaction, after ESPH2SO4 HCl HF HCl + HF

lb m ole/hr lb/hr lb/hr lb/hr lb/hr lb/m mbtu lb/m mbtu lb/Mm btu lb/hr
0.000 **0.00** 12.52 **12.27** 153.81 0.00190 0 0 0.00

**1.87** 129.62 0.00027 0 0 0.00

0.000 **0.00** 13.04 **12.77** 183.16 0.00190 0 0 0.00 Total Effective SO4 for modeling Total PM10 [NH3] after reaction Net NH3

after reaction & WFGD H2SO4 +

AbS + AS post-controlHCl+HF+

Pmfine HCl+HF+

Pmfine EC coarse SO4 organic new PM fine lb/m mbtu lb/m mbtu lb/m mbtu lb/m mbtu lb/m mbtu
47.89 0.007 0.00028 0.010 0.00186 0.0040

41.45 0.006 0.00023 0.008 0.00026 0.0040

59.46 0.009 0.00033 0.012 0.00186 0.0040

### For copying to Word version of tables Highlight num bers portion of table here, copy; then in Word, highlight num bers section of its table, paste **f8: SCR on #1,#3; reduce capy by 561 MW on all three equally** Filterable PM10

Max Heat Input SO2 NOx H2SO4 NH3 PM coarse PM fine soil MMBtu/hr lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu
Unit 1 6,596 0.06 0.07 0.00190 0 0.010 0.007

Unit 2 7,068 0.06 0.24 0.00027 0 0.008 0.006

Unit 3 6,868 0.06 0.07 0.00190 0 0.012 0.009

Filterable PM10 Max Heat SO2 NOx H2SO4 NH3 PM coarse PM fine MMBtu/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr Unit 1 6,596 365.81 461.72 12.52 0 65.17 47.89 Unit 2 7,068 395.19 1696.22 1.91 0 56.40 41.45 Unit 3 6,868 432.13 480.76 13.04 0 80.91 59.46Highlight num bers portion of table here, copy; then in Word, highlight num bers section of its table, paste
Condensable PM10 (CPM) Filterable PM PM fine EC inorganic

(SO4) organic

(SOA) Max Stack

Test lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu
0.00028 0.00186 0.0040 0.026

0.00023 0.00026 0.0040 0.021

0.00033 0.00186 0.0040 0.031

Condensable PM10 (CPM) Filterable PM 

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals PM fine inorganic organic Max Stack lb/hr lb/hr lb/hr lb/hr scen SRCNAM **SO2 SO4**  **NOX** 1.84 12.27 26.38 171.50 f8 **NGS1** 365.81 12.27 461.72 1.59 1.87 28.27 148.42 f8 **NGS2** 395.19 1.87 1696.22 2.28 12.77 27.47 212.91 f8 **NGS3** 432.13 12.77 480.76

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals

**HNO3 NO3**  **SOA PM**  **F PM**  **C EC**  0 0 26.38 47.89 65.17 1.84 0 0 28.27 41.45 56.40 1.59 0 0 27.47 59.46 80.91 2.28**EPA revisions to values used in Proposed Rule** 

MMBtu/day MMBtu/hr % ton/day lb/hr Navajo 1 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, **LNB** , SOFA, hot side ESP, wet FGD **131,921** 5,497 0.593 **3.66** 304.84

Navajo 2 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, **LNB** , SOFA, hot side ESP, wet FGD 226,163 9,423 0.593 6.32 526.92

Navajo 3 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, **LNB** , SOFA, hot side ESP, wet FGD **137,361** 5,723 0.593 **4.32** 360.10 

### ** Below**are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately** (a) Maximum daily

24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02. (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or ma lfunction. (d) Maximum daily

/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. (f) For a dry

bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (h) Total condensable PM10 is the sum of H2SO4 and organic condensible PM10 emissions. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. EPRI (2008) Eqn 4-2b indicates that 95% of fuel sulfur is converted to SO2. (j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998. (e) Maximum of 6 stack test results for the 2001 to 2006 period. 

## f9: Reduce net capacity **on equally**

**on Units 1 and 3 by**

**561 MW total; operate w ith LNB+SOFA**  **on Unit 2, install SCR+LNB+SOFA on Units 1 and 3** 
Facility Unit Description Maximum Heat Input (a) Maximum Sulfur Content (b) Maximum SO2 Emissions

### EPA

**Revisions for Final Rule** (1) Decrease total net capacity on all 3 units equally

by 561 MW . (i.e., apply

factor of 0.75 to daily

heat input for each unit - from 1-(561/2250)) (2) install and operate SCR on the two units still at full capacity (3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for PRB coal (strongly

alkaline coal) 

### EPA revisions to Values used in ANPRM (3-7-11) (1) set HCl and HF to zero (2) in sulfuric acid calculation, revised penetration factor for hot-side ESP from 1 (used in ANPRM) to 0.63.lb/MMBtu % reduction ton/day lb/hr lb/MMBtu lb/MMBtu (e) lb/hr lb/hr

0.055 91% 4.62 384.77 **0.070** 0.0260 142.91 95.75 (f)

0.056 46% 27.14 2,261.63 **0.240** 0.0210 197.89 132.59 (f)

0.063 90% 4.81 400.64 **0.070** 0.0310 177.42 118.87 (f) 

### ** Below**are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately** (a) Maximum daily

24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02. (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or (d) Maximum daily

/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. (f) For a dry

bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. (j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998. total 

## Maximum Emissions Including Speciated PM **f9: Reduce net capacity on equally** 

**on Units 1 and 3 by**

**561 MW total; operate w ith LNB+SOFA**  **on Unit 2, install SCR+LNB+SOFA on Units 1 and 3** 
Maximum SO2 Emissions (c) Maximum NOx Emissions (d) Maximum Filterable PM Em issions(1) Decrease total net capacity on all 3 units equally

by 561 MW . (i.e., apply

factor of 0.75 to daily

heat input for each unit - from 1-(561/2250)) (3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 forfine total fine soil EC

lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr 54.31 (f) 41.45 (f) 39.9 (g) 1.53 (g) 32.42 (h) 10.44 (i) 10.22 21.99 (j)

75.20 (f) 57.39 (f) 55.3 (g) 2.12 (g) 40.24 (h) 2.54 (i) 2.49 37.69 (j)

67.42 (f) 51.45 (f) 49.5 (g) 1.90 (g) 33.76 (h) 10.87 (i) 10.64 22.89 (j)

(c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. coarse Fine total H2SO4 SO4 organic 

## Maximum Emissions Including Speciated PM **10**

## Emissions

**Navajo Units 1, 2, and 3 f9: Reduce net capacity**  **on equally**

**on Units 1 and 3 by**

**561 MW total; operate w ith LNB+SOFA**  **on Unit 2, install SCR+LNB+SOFA on Units 1 and 3**  Filterable PM 10 Condensable PM 10(3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 forlb/hr lb/hr lb m ole/hr lb m ole/hr mole ratio lb m ole/hr lb m ole/hr lb m ole/hr

44.41 0.00 (k) 0.000 0.453 0.000 0.453 0.000 0.000

10.82

46.24 0.00 (k) 0.000 0.471 0.000 0.471 0.000 0.000 [AS] or [(NH4)2SO 4] after reaction [H2SO4] [NH3] /

[H2SO4] ratio [H2SO4]

after reaction [AbS] or

[NH4HSO4] after reaction NH3 Slip [NH3] H2SO4 before NH3 interaction, after ESPH2SO4 HCl HF HCl + HF

lb m ole/hr lb/hr lb/hr lb/hr lb/hr lb/m mbtu lb/m mbtu lb/Mm btu lb/hr
0.000 **0.00** 10.44 **10.22** 128.18 0.00190 0 0 0.00

**2.49** 172.82 0.00027 0 0 0.00

0.000 **0.00** 10.87 **10.64** 152.63 0.00190 0 0 0.00 Total Effective SO4 for modeling Total PM10 [NH3] after reaction Net NH3

after reaction & WFGD H2SO4 +

AbS + AS post-controlHCl+HF+

Pmfine HCl+HF+

Pmfine EC coarse SO4 organic new PM fine lb/m mbtu lb/m mbtu lb/m mbtu lb/m mbtu lb/m mbtu
39.91 0.007 0.00028 0.010 0.00186 0.0040

55.27 0.006 0.00023 0.008 0.00026 0.0040

49.55 0.009 0.00033 0.012 0.00186 0.0040

### For copying to Word version of tables Highlight num bers portion of table here, copy; then in Word, highlight num bers section of its table, paste **f9: SCR on #1,#3; reduce capy by 561 MW on #1, #3** Filterable PM10

Max Heat Input SO2 NOx H2SO4 NH3 PM coarse PM fine soil MMBtu/hr lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu
Unit 1 5,497 0.06 0.07 0.00190 0 0.010 0.007

Unit 2 9,423 0.06 0.24 0.00027 0 0.008 0.006

Unit 3 5,723 0.06 0.07 0.00190 0 0.012 0.009

Filterable PM10 Max Heat SO2 NOx H2SO4 NH3 PM coarse PM fine MMBtu/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr Unit 1 5,497 304.84 384.77 10.44 0 54.31 39.91 Unit 2 9,423 526.92 2261.63 2.54 0 75.20 55.27 Unit 3 5,723 360.10 400.64 10.87 0 67.42 49.55Highlight num bers portion of table here, copy; then in Word, highlight num bers section of its table, paste
Condensable PM10 (CPM) Filterable PM PM fine EC inorganic

(SO4) organic

(SOA) Max Stack

Test lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu
0.00028 0.00186 0.0040 0.026

0.00023 0.00026 0.0040 0.021

0.00033 0.00186 0.0040 0.031

Condensable PM10 (CPM) Filterable PM 

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals PM fine inorganic organic Max Stack lb/hr lb/hr lb/hr lb/hr scen SRCNAM **SO2 SO4**  **NOX** 1.53 10.22 21.99 142.91 f9 **NGS1** 304.84 10.22 384.77 2.12 2.49 37.69 197.89 f9 **NGS2** 526.92 2.49 2261.63 1.90 10.64 22.89 177.42 f9 **NGS3** 360.10 10.64 400.64

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals

**HNO3 NO3**  **SOA PM**  **F PM**  **C EC**  0 0 21.99 39.91 54.31 1.53 0 0 37.69 55.27 75.20 2.12 0 0 22.89 49.55 67.42 1.90**Parameter Unit 1**  **Unit 2 Unit 3**  **Parameter Unit 1**  **Unit 2 Unit 3** 

Height, ft 775 775 775 Height, m 236.2 236.2 236.2 Diam eter, ft 24.5 24.5 24.50 Diam eter, m 7.47 7.47 7.47 Flow, acfm 2,497,502 2,497,502 2,497,502 Flow, m 3/s 1,178.7 1,178.7 1,178.7 Temperature, F 119 119 119 Temperature, K 321.5 321.5 321.5 Exit velocity, ft/min 5,298 5,298 5,298 Exit velocity, m/s 26.91 26.91 26.91 LC-X (km) -1267.800 -1267.790 -1267.750 LC-Y (km) -241.690 -241.784 -241.884 

## Navajo G.S. Stack Data **(a)**

09000064817e49bb 

# Baseline stack data 7/28/2014**EPA revisions to values used in ANPRM**
fine total fine soil EC MMBtu/day MMBtu/hr % ton/day lb/hr lb/MMBtu % reduction ton/day lb/hr lb/MMBtu lb/MMBtu (e) lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr Navajo 1 750 MW , PC,

biituminous coal, dry bottom, tangential fired, hot side ESP, wet FGD 211,074 8,795 0.593 5.85 487.75 0.055 #N/A 51.26 4,271.42 0.486 0.0260 228.66 153.20 (f) 86.89 (f) 66.31 (f) 63.9 (g) 2.45 (g) 37.55 (h) 2.37 (i) 2.32 35.18 (j) 190.76

Navajo 2 750 MW , PC,

biituminous coal, dry bottom, tangential fired, hot side ESP, wet FGD 226,163 9,423 0.593 6.32 526.92 0.056 #N/A 50.49 4,207.50 0.446 0.0210 197.89 132.59 (f) 75.20 (f) 57.39 (f) 55.3 (g) 2.12 (g) 40.24 (h) 2.54 (i) 2.49 37.69 (j) 172.82

Navajo 3 750 MW , PC,

biituminous coal, dry bottom, tangential fired, hot side ESP, wet FGD 219,778 9,157 0.593 6.91 576.17 0.063 #N/A 50.18 4,181.67 0.457 0.0310 283.88 190.20 (f) 107.87 (f) 82.33 (f) 79.3 (g) 3.05 (g) 39.10 (h) 2.47 (i) 2.42 36.63 (j) 229.30   Below** **are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately**

(i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. EPRI (2008) Eqn 4-2b indicates that 95% of fuel sulfur is converted to SO2. Maximum Heat Input (a)

(f) For a dry bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. (e) Maximum of 6 stack test results for the 2001 to 2006 period. (h) Total condensible PM10 is the sum of H2SO4 and organic condensible PM10 emissions. (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiam Battye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. total

(d) Maximum daily 24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. (c) Maximum daily 24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or (a) Maximum daily 24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02. Total PM10

Unit Maximum NOx Emissions (d)

(j) Organic condensible PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998. 

### Maximum Emissions Including Speciated PM **10**

### Emissions

Filterable PM 10 Condensable PM 10 Fine Maximum Filterable PM Emissions Description 

### Navajo Units 1, 2, and 3 **Baseline Conditions**
Maximum SO2 Emissions (c) organic H2SO4 coarse total SO4 Maximum Sulfur Content (b) Facility

09000064817e49bb 

### n0 Base 7/28/2014**EPA revisions to values used in ANPRM**
fine total fine soil EC MMBtu/day MMBtu/hr % ton/day lb/hr lb/MMBtu % reduction ton/day lb/hr lb/MMBtu lb/MMBtu (e) lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr Navajo 1 750 MW , PC,

bituminous coal, dry bottom, tangential fired, **LNB** , SOFA, hot side ESP, wet FGD 211,074 8,795 0.593 5.85 487.75 0.055 51% 25.33 2,110.74 0.240 0.0260 228.66 153.20 (f) 86.89 (f) 66.31 (f) 63.9 (g) 2.45 (g) 37.55 (h) 2.37 (i) 2.32 35.18 (j) 190.76

Navajo 2 750 MW , PC,

bituminous coal, dry bottom, tangential fired, **LNB** , SOFA, hot side ESP, wet FGD 226,163 9,423 0.593 6.32 526.92 0.056 46% 27.14 2,261.63 0.240 0.0210 197.89 132.59 (f) 75.20 (f) 57.39 (f) 55.3 (g) 2.12 (g) 40.24 (h) 2.54 (i) 2.49 37.69 (j) 172.82

Navajo 3 750 MW , PC,

bituminous coal, dry bottom, tangential fired, **LNB** , SOFA, hot side ESP, wet FGD 219,778 9,157 0.593 6.91 576.17 0.063 47% 26.37 2,197.78 0.240 0.0310 283.88 190.20 (f) 107.87 (f) 82.33 (f) 79.3 (g) 3.05 (g) 39.10 (h) 2.47 (i) 2.42 36.63 (j) 229.30 

### Maximum Emissions Including Speciated PM **10**

### Emissions

Total PM 10 Filterable PM 10 Condensable PM 10

Fine Maximum Filterable PM Emissions Description Unit total Maximum Sulfur Content (b) 

### Navajo Units 1, 2, and 3 **Control Option 1: Low NOx Burners and Separated Overfire A ir** 

H2SO4 organic Facility Maximum SO2 Emissions (c) total Maximum Heat Input (a)

(j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. EPRI (2008) Eqn 4-2b indicates that 95% of fuel sulfur is converted to SO2. **** Below are the Original footnotes from A** **ECOM - EPA revisions to the footnotes/emission inputs are explained separately**  (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. coarse SO4 Maximum NOx Emissions (d)

(a) Maximum daily 24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02. (c) Maximum daily 24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or malfunction. (d) Maximum daily/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. (e) Maximum of 6 stack test results for the 2001 to 2006 period. (h) Total condensable PM10 is the sum of H2SO4 and organic condensible PM10 emissions. (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiam Battye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (f) For a dry bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998.

09000064817e49bb 

### n1 LNB 7/28/2014

### Control Option 8: Low**NOx Burners, Separated Overfire A ir, and Selective Non-Cataly** **tic Reduction at 0.18 lb/MMBtu (Units 1, 2 & 3)**

MMBtu/day MMBtu/hr % ton/day lb/hr Navajo 1 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, LNB, SOFA, **SNCR**, hot side ESP, wet FGD 211,074 8,795 0.593 5.85 487.75

Navajo 2 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, LNB, SOFA, **SNCR**, hot side ESP, wet FGD 226,163 9,423 0.593 6.32 526.92

Navajo 3 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, LNB, SOFA, **SNCR**, hot side ESP, wet FGD 219,778 9,157 0.593 6.91 576.17

Unit conversion for ammonia slip from ppmvd to lb/hr NH3 5.00 ppmvd at 6% O2 Facility Unit Description Maximum Heat Input (a) Maximum Sulfur Content (b) Maximum SO2 Emissions

(f) For a dry

bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. 

### ** Below**are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately** (a) Maximum daily

24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02. (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or malfunction. (d) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. (e) Maximum of 6 stack test results for the 2001 to 2006 period. (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (h) Total condensible PM10 is the sum of H2SO4 and organic condensible PM10 emissions. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. EPRI (2008) Eqn 4-2b indicates that 95% of fuel sulfur is converted to SO2. (j) Organic condensible PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998.0.00302 lb/MMBtu unit 1 26.60 lb/hr unit 2 28.50 lb/hr unit 3 27.69 lb/hr

Penetration factors H2SO4 AbS and AS PM, general p % ctrl p % ctrl p hot-side ESP 0.63 37% 0.01 99% 0.01 Air Preheater 0.50 50% 0.75 25% Wet FGD (scrubber) 0.47 53% 0.50 50% EPRI H2SO4 doc EPRI NH3 doc (2) updated Ammonia-Sulfuric acid reaction to accommodate full range of NH3/H2SO4 ratios, and accounted for molecular weight of ammonium sulfate (AS) and bisulfate (AbS) (2) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for PRB coal (strongly

alkaline coal) 

### EPA **revisions** (1) in sulfuric acid calculation, revised penetration factor for hot-side ESP from 1 (used in ANPRM) to 0.63.

### Control Option 8: Low**NOx Burners, Separated Overfire A ir, and Selective Non-Cataly** **tic Reduction at 0.18 lb/MMBtu (Units 1, 2 & 3)**

lb/MMBtu % reduction ton/day lb/hr lb/MMBtu lb/MMBtu (e) lb/hr lb/hr
0.055 63% 19.00 1,583.06 0.180 0.026 228.66 153.20 (f)

0.056 60% 20.35 1,696.22 0.180 0.021 197.89 132.59 (f)

0.063 61% 19.78 1,648.34 0.180 0.031 283.88 190.20 (f)

Method 19 (SO2 removal efficiency) formula, Eq. 19-1: total 

## Maximum Emissions Including Speciated PM **10**

## Emissions

**Navajo Units 1, 2, and 3**

Maximum SO2 Emissions (c) Maximum NOx Emissions (d) Maximum Filterable PM Em issions

(f) For a dry

bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. 

### ** Below**are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately** (a) Maximum daily

24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02. (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown (d) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x (j) Organic condensible PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998.E = Cd*Fd*20.9/(20.9 - %O2d) Atm osphere is 20.9% oxygen

Cd = Pollutant concentration, dry basis Am monia M.W . is 17 lb/lb.mol Fd = volum es of combustion components per unit of heat content 385 ft3/lb-mol = volume of 1 ft3 of gas at STP %O2d = Concentration of oxygen on a dry basis, percent. Table 19-2 gives F factor for bituminous coal as Fd = 9780 sdcf/10^6 Btu

% ctrl 99% (2) updated Ammonia-Sulfuric acid reaction to accommodate full range of NH3/H2SO4 ratios, and accounted for molecular weight of ammonium sulfate (AS) and bisulfate (AbS) (2) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 forfine total fine soil EC

lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr 86.89 (f) 66.31 (f) 63.9 (g) 2.45 (g) 37.55 (h) 2.37 (i) 35.18 (j) 10.10

75.20 (f) 57.39 (f) 55.3 (g) 2.12 (g) 40.24 (h) 2.54 (i) 37.69 (j) 10.82

107.87 (f) 82.33 (f) 79.3 (g) 3.05 (g) 39.10 (h) 2.47 (i) 36.63 (j) 10.52 coarse Fine total H2SO4 Filterable PM 10 Condensable PM 10 H2SO4 before NH3 interaction, after ESP organic

(c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input xAtm osphere is 20.9% oxygen Am monia M.W . is 17 lb/lb.mol 385 ft3/lb-mol = volume of 1 ft3 of gas at STP
(2) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 forlb/hr lb m ole/hr lb m ole/hr mole ratio lb m ole/hr lb m ole/hr lb m ole/hr lb m ole/hr

26.60 (k) 1.562 0.103 15.167 0.000 0.000 0.103 1.356

28.50 (k) 1.673 0.110 15.167 0.000 0.000 0.110 1.453

27.69 (k) 1.626 0.107 15.167 0.000 0.000 0.107 1.412

[NH3] [NH3] after reaction [H2SO4] [NH3] /

[H2SO4] ratio [H2SO4]

after reaction [AbS] or

[NH4HSO4] after reaction NH3 Slip Am monia slip and reaction with sulfuric acid, for Net ammonia slip and Modeling SO4 [AS] or [(NH4)2SO 4] after reaction

### For copying to Word version of tables Highlight num bers portion of table here, copy; then in Word, highlight num bers section of its table, paste **Control Option 8: SNCR Units 1 - 3**

Max Heat Input SO2 NOx lb/hr lb/hr lb/hr lb/hr MMBtu/hr lb/MMBtu lb/MMBtu
2.309 3.197 2.32 191.58 Unit 1 8,795 0.06 0.18

2.474 3.426 2.490 173.708 Unit 2 9,423 0.06 0.18

2.404 3.329 2.420 230.158 Unit 3 9,157 0.06 0.18

Max Heat Input SO2 NOx MMBtu/hr lb/hr lb/hr Unit 1 8,795 487.75 1583.06 Unit 2 9,423 526.92 1696.22 Unit 3 9,157 576.17 1648.34 4927.61 Total PM10 Net NH3 after reaction & WF GD H2SO4 +

AbS + AS post-control Total

Effective SO4 for modeling Am monia slip and reaction with sulfuric acid, for Net ammonia slip and Modeling SO4

### For copying to Word version of tables Highlight num bers portion of table here, copy; then in Word, highlight num bers section of its table, paste

Filterable PM10 Condensable PM10 (CPM) Filterable PM H2SO4 NH3 PM coarse PM fine soil PM fine

EC inorganic

(SO4) organic

(SOA) Max Stack

Test lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu
0.0003 0 0.010 0.000 0.00028 0.0003 0.0040 0.026

0.0003 0 0.008 0.000 0.00023 0.0003 0.0040 0.021

0.0003 0 0.012 0.000 0.00033 0.0003 0.0040 0.031

Filterable PM10 Condensable PM10 (CPM) Filterable PM 

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals H2SO4 NH3 PM coarse PM fine soil PM fine

EC inorganic

(SO4) organic

(SOA) Max Stack

Test lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr scen 2.37 0 86.89 0.03 2.45 2.32 35.18 228.66 n8 16.70 0 75.20 0.02 2.12 2.49 37.69 197.89 n8 16.70 0 107.87 0.03 3.05 2.42 36.63 283.88 n8

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals

SRCNAM **SO2 SO4**  **NOX HNO3**  **NO3 SOA**  **PM F**  **PM C**  **EC NGS1**  487.75 2.32 1583.06 0 0 35.18 0.03 86.89 2.45 **NGS2** 526.92 2.49 1696.22 0 0 37.69 0.02 75.20 2.12 **NGS3** 576.17 2.42 1648.34 0 0 36.63 0.03 107.87 3.05

### NFRM CA**LPUFF Emissions, lb/hr** 

**Scenario Name Code**  **SRCNA M**  **SO2 SO4**  **NOX HNO3**  **NO3 SOA**  **PM F**  **PM C**  **EC** NGS1 487.75 16.35 483.71 0 0 35.18 63.86 86.89 2.45 NGS2 526.92 17.52 518.29 0 0 37.69 55.27 75.20 2.12 NGS3 576.17 17.03 503.66 0 0 36.63 79.28 107.87 3.05 NGS1 487.75 2.32 2110.74 0 0 35.18 63.86 86.89 2.45 NGS2 0 0 0 0 0 0 0 0 0 NGS3 576.17 2.42 2197.78 0 0 36.63 79.28 107.87 3.05 NGS1 487.75 16.35 615.63 0 0 35.18 63.86 86.89 2.45 NGS2 0 0 0 0 0 0 0 0 0 NGS3 576.17 17.03 641.02 0 0 36.63 79.28 107.87 3.05 NGS1 549.21 2.62 2376.69 0 0 39.61 71.91 97.84 2.76 NGS2 0 0 0 0 0 0 0 0 0 NGS3 648.76 2.73 2474.70 0 0 41.25 89.27 121.47 3.43 NGS1 549.21 18.41 693.20 0 0 39.61 71.91 97.84 2.76 NGS2 0 0 0 0 0 0 0 0 0 NGS3 648.76 19.17 721.79 0 0 41.25 89.27 121.47 3.43 NGS1 487.75 2.32 2110.74 0 0 35.18 63.86 86.89 2.45 NGS2 132.78 0.63 569.93 0 0 9.50 13.93 18.95 0.54 NGS3 576.17 2.42 2197.78 0 0 36.63 79.28 107.87 3.05 NGS1 487.75 16.36 615.63 0 0 35.18 63.86 86.89 2.45 NGS2 132.78 0.63 569.93 0 0 9.50 13.93 18.95 0.54 NGS3 576.17 17.03 641.02 0 0 36.63 79.28 107.87 3.05 NGS1 365.81 12.27 461.72 0 0 26.38 47.89 65.17 1.84 NGS2 395.19 1.87 1696.22 0 0 28.27 41.45 56.40 1.59 NGS3 432.13 12.77 480.76 0 0 27.47 59.46 80.91 2.28 NGS1 304.84 10.22 384.77 0 0 21.99 39.91 54.31 1.53 NGS2 526.92 2.49 2261.63 0 0 37.69 55.27 75.20 2.12 NGS3 360.10 10.64 400.64 0 0 22.89 49.55 67.42 1.90 NGS1 487.75 2.32 4271.42 0 0 35.18 63.86 86.89 2.45 NGS2 526.92 2.49 4207.50 0 0 37.69 55.27 75.20 2.12 NGS3 576.17 2.42 4181.67 0 0 36.63 79.28 107.87 3.05 NGS1 487.75 2.32 2110.74 0 0 35.18 63.86 86.89 2.45 NGS2 526.92 2.49 2261.63 0 0 37.69 55.27 75.20 2.12 NGS3 576.17 2.42 2197.78 0 0 36.63 79.28 107.87 3.05 NGS1 487.75 2.32 1583.06 0 0 35.18 0.03 86.89 2.45 NGS2 526.92 2.49 1696.22 0 0 37.69 0.02 75.20 2.12 NGS3 576.17 2.42 1648.34 0 0 36.63 0.03 107.87 3.05 Baseline **n0** Control 1: LNB **n1** Control 8: SNCR **n8** TW G A3-2031a **f7** TW G A3-2031b **f8** TW G A3-2013c **f9** TW G A2-2020 **f4** TW G A2-2031 **f5** TW G A3-2020 **f6** SCR is BART **f1** TW G A1-2020 **f2** TW G A1-2031 **f3**

### NFRM CA**LPUFF**

**Scenario Name Code** 

Baseline **n0** Control 1: LNB **n1** Control 8: SNCR **n8** TW G A3-2031a **f7** TW G A3-2031b **f8** TW G A3-2013c **f9** TW G A2-2020 **f4** TW G A2-2031 **f5** TW G A3-2020 **f6** SCR is BART **f1** TW G A1-2020 **f2** TW G A1-2031 **f3 Percent change from Baseline (n0) Emissions**  SO2 SO4 NOX HNO3 NO3 SOA PMF PMC EC

-- 604.7% -88.7% -- -- -- -- -- --

-- 603.6% -87.7% -- -- -- -- -- --

-- 603.7% -88.0% -- -- -- -- -- --

-- -- -50.6% -- -- -- -- -- -- -100% -100% -100% -- -- -100% -100% -100% -100%

-- -- -47.4% -- -- -- -- -- --

-- 604.7% -85.6% -- -- -- -- -- -- -100% -100% -100% -- -- -100% -100% -100% -100%

-- 603.7% -84.7% -- -- -- -- -- -- 12.6% 12.9% -44.4% -- -- 12.6% 12.6% 12.6% 12.7% -100% -100% -100% -- -- -100% -100% -100% -100% 12.6% 12.8% -40.8% -- -- 12.6% 12.6% 12.6% 12.5% 12.6% 693.5% -83.8% -- -- 12.6% 12.6% 12.6% 12.7% -100% -100% -100% -- -- -100% -100% -100% -100% 12.6% 692.1% -82.7% -- -- 12.6% 12.6% 12.6% 12.5%

-- -- -50.6% -- -- -- -- -- -- -74.8% -74.7% -86.5% -- -- -74.8% -74.8% -74.8% -74.5%

-- -- -47.4% -- -- -- -- -- --

-- 605.2% -85.6% -- -- -- -- -- -- -74.8% -74.7% -86.5% -- -- -74.8% -74.8% -74.8% -74.5%

-- 603.7% -84.7% -- -- -- -- -- -- -25.0% 428.9% -89.2% -- -- -25.0% -25.0% -25.0% -24.9% -25.0% -24.9% -59.7% -- -- -25.0% -25.0% -25.0% -25.0% -25.0% 427.7% -88.5% -- -- -25.0% -25.0% -25.0% -25.2% -37.5% 340.5% -91.0% -- -- -37.5% -37.5% -37.5% -37.6%

-- -- -46.2% -- -- -- -- -- -- -37.5% 339.7% -90.4% -- -- -37.5% -37.5% -37.5% -37.7%

-- -- -- -- -- -- -- -- --

-- -- -- -- -- -- -- -- --

-- -- -- -- -- -- -- -- --

-- -- -50.6% -- -- -- -- -- --

-- -- -46.2% -- -- -- -- -- --

-- -- -47.4% -- -- -- -- -- --

-- -- -62.9% -- -- -- -99.95% -- --

-- -- -59.7% -- -- -- -99.96% -- --

-- -- -60.6% -- -- -- -99.96% -- --